CN106050213A - Sandstone reservoir self-diverting acidizing method - Google Patents
Sandstone reservoir self-diverting acidizing method Download PDFInfo
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- CN106050213A CN106050213A CN201610513187.4A CN201610513187A CN106050213A CN 106050213 A CN106050213 A CN 106050213A CN 201610513187 A CN201610513187 A CN 201610513187A CN 106050213 A CN106050213 A CN 106050213A
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/62—Compositions for forming crevices or fractures
- C09K8/72—Eroding chemicals, e.g. acids
- C09K8/74—Eroding chemicals, e.g. acids combined with additives added for specific purposes
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices, or the like
- E21B33/138—Plastering the borehole wall; Injecting into the formation
Abstract
The invention discloses a sandstone reservoir self-diverting acidizing method, which comprises the following steps of (1) injecting diverting acid into a sandstone reservoir to be used as ahead liquid; (2) injecting processing liquid into the sandstone reservoir; (3) injecting subsequent liquid into the sandstone reservoir; and (4) injecting displacing liquid into a pit shaft, and jacking acid liquid in the pit shaft into the deep path of the reservoir. The diverting acid is prepared from the following ingredients including 12 to 15 percent of HCl, 3 to 10 percent of diverting agents, 4 to 8 percent of additives and the balance water, wherein the diverting agents are erucyl amide hydroxysulfobetaine; the processing liquid is various kinds of conventional processing liquid suitable for sandstone acidizing; the subsequent liquid is prepared from the following ingredients including 5 to 15 percent of HCl, 1 to 2 percent of gel breakers, 4 to 8 percent of additives and the balance water; the displacing liquid is diesel oil, gasoline or 3-percent ammonium chloride solution. The percentage of the ingredients is mass percentage. The sandstone reservoir self-diverting acidizing method has the advantages that the uniform acid distribution effect of the acid liquid in the reservoir can be improved; the subsequent gel breaking residue is reduced; and the inhomogenous reservoir acidification is realized.
Description
Technical field
The side of heterogeneous body sandstone reservoir acidizing effect is improved during the present invention relates to oil-gas field development field matrix acidifying
Method, particularly relates to a kind of sandstone reservoir low damage distributary acid method.
Background technology
Dividing technology is turned to mainly to have three kinds: one to be to use packer tool to layer for the existing conventional acidulation of sandstone reservoir
Between or the bigger well of perforated interval spacing carry out selective divided-flow acidifying, the reservoir making major part there is vertical heterogeneity obtains
It is effectively improved, but there is the biggest limitation simultaneously, on the one hand easily cause relatively by force due to formation heterogeneity during conventional acidulation
Acid solution is " fingering " in high permeability formation macropore and crack, it is impossible to make hypotonic interval and little duct are effectively acidified, on the other hand
Cannot use instrument packing acidifying for the well that interlayer or perforated interval spacing are less, it is loaded down with trivial details that the third aspect plays lower packet technique
Construction cost is high.Two is to use granular pattern to block up diversion agent temporarily to carry out distributary acid, mainly includes sodium benzoate and phenolic resin, but
This two classes chemical substance there is also limitation in construction, and in work progress, the particle diameter of granule cannot be different because of reservoir pore space diameter
And reach the most stifled shunting effect, in work progress, solid phase particles one enters pit shaft and will form solid phase at the borehole wall simultaneously
Cake fills and can not enter high seepage hole and reach the most stifled shunting effect.Three is to use thickening type to turn to diversion agent to carry out shunting acid
Changing, mainly include polymeric viscosifiers and viscoelastic surfactant, this two classes chemical substance is currently used primarily in carbonate rock
Reservoir Acidization pressure break carries out constructing and reaches to reduce the effect of leak-off, this two class for sandstone reservoir have again himself deficiency it
Place, polymer residue is serious, and viscoelastic surfactant also has the shortcoming of self in sandstone reservoir steering procedure, due to
Sandstone reservoir hydrochloric acid solubles content is low, and causes secondary injury to produce reservoir to reduce treatment fluid in work progress,
Therefore high concentration H must be kept in haveing suffered work progress+If, the most directly with viscoelastic surfactant as sandstone acid
Change diversion agent, easily causes acid solution in acidization and breaks glue difficulty, cause acid solution to be difficult to the row of returning.
In order to solve the existing distributary acid technical deficiency used for heterogeneous body sandstone reservoir in oil field so that long well section
The problem of heterogeneous body sandstone reservoir acidizing effect difference, research is applicable to the new skill of acidifying of sandstone reservoir acidizing treatment practical situation
Art, has been the task of top priority.
Summary of the invention
It is an object of the invention to provide a kind of sandstone reservoir low damage distributary acid method, the method principle is reliable, behaviour
Make simplicity, acid solution can be improved and in reservoir uniform acid distribution effect and reduce follow-up broken glue residual, it is achieved heterogeneous reservoir substrate
Acidifying, overcomes the deficiencies in the prior art.
For reaching above technical purpose, the present invention provides techniques below scheme.
A kind of sandstone reservoir low damage distributary acid method, comprises the following steps successively:
(1) turn to acid as prepad fluid to sandstone reservoir injection；
(2) treatment fluid is injected to layer of sand reservoir；
(3) after pad is injected to sandstone reservoir；
(4) inject displacement fluid to pit shaft, the acid solution in pit shaft is headed into reservoir deep.
In concrete construction operation, step (1), (2), (3) 1-5 time can be repeated, it is also possible to do not repeat.Owing to executing
During work, prepad fluid is to realize the key that treatment fluid turns to, along with acid solution is progressively goed deep into before stratum contacts with formation water and can make
Put liquid concentration to be diluted, cause turning efficiency to be slowly deteriorated, use the mode alternately injected can realize the place replaced each time
Reason liquid can preferably turn to, it is possible to achieve the deep on stratum turns to acidifying, turns to acid energy in order to ensure to go deep into stratum simultaneously
Broken glue, need to repeat step (3), the rapid break after acidifying.
Described turning to acid, composed of the following components: HCl 12-15%, diversion agent 3-10%, additive 4-8%, remaining is
Water；Described diversion agent is erucyl amide hydroxysultaine；Described additive includes that corrosion inhibiter 1-2%, iron ion are steady
Determine agent 1-2%, clay stabilizer 1-2%, cleanup additive 1-2%.
Described treatment fluid applies to the various conventional treatment liquid of sandstone acidizing, including mud acid system, fluoboric acid system, many
Hydracid system, organic sandstone acid system or Compound-acid system.
Described after pad is composed of the following components: HCl 5-15%, gel breaker 1-2%, additive 4-8%, and remaining is water；
Described gel breaker is butyl or butyl glycol ether；Described additive includes corrosion inhibiter 1-2%, ferrous stability 1-
2%, clay stabilizer 1-2%, cleanup additive 1-2%.
Described displacement fluid is diesel oil, gasoline or 3% ammonium chloride solution.
Above component is mass percent.
Described corrosion inhibiter is 4-picoline, butynediols, formaldehyde one or more of which.
Described ferrous stability is citric acid, nitrilotriacetic acid, EDTA tetrasodium salt one or more of which.
Described clay stabilizer is polymeric aluminum chloride.
Described cleanup additive is Polyethylene Glycol, perfluor 2,5,8-trimethyl-3,6,9-trioxa lauric acid/dodecanoic acid (salt) or its mixing
Thing.
After turning to acid to inject reservoir, due to the anisotropism of reservoir, acid solution initially enters Gao Konggao after entering reservoir and oozes
District, then with the reduction of acid strength, acid liquid viscosity raises rapidly, and the when of then reinjecting treatment fluid, treatment fluid would not enter
Enter to enter in a large number height and ooze reservoir, and turn to low permeability reservoir, thus be finally reached the effect of homogeneous acidification.
Compared with prior art, beneficial effects of the present invention is as follows:
(1) with mechanical steering Technical comparing, the present invention is easy and simple to handle, and the shunting that can realize heterogeneity turns to acid
Change.
(2) comparing with chemical particle steering technique, the present invention can go deep into reservoir and turn to, and granule is typically easy to block up at the borehole wall
Plug.
(3) comparing with polymer steering technique, in the present invention, diversion agent is a kind of Small molecular surfactant, reduces polymerization
The thing injury to reservoir.
Accompanying drawing explanation
Fig. 1 is that embodiment 1 is acidified experiment effect curve chart.
Fig. 2 is that embodiment 2 is acidified experiment effect curve chart.
Fig. 3 is the concentration of hydrochloric acid impact on turning to acid viscosity.
Fig. 4 is the temperature impact on turning to acid viscosity.
Fig. 5 is to turn to acid shunting effect empirical curve.
Fig. 6 is D16H well construction curve.
Detailed description of the invention
Below by drawings and Examples, (percentage ratio occurred herein is percent mass to further illustrate the present invention
Than).
Embodiment 1: in CNOOC's Bohai Sea as a example by the rock core simulating lab test of SZ36-1 oil field, be described in detail.
The side by side double cores using permeability different carry out flowing experiment simulation under formation conditions due to reservoir non-all
The fluid that matter causes is at the permeability of reservoir.1# core: the long 7cm of rock core, diameter 2.54cm, porosity 27.5%, permeability
683×10-3μm2, 2# core: the long 7cm of rock core, diameter 2.54cm, porosity 9.6%, permeability 38 × 10-3μm2.Simulation oil reservoir
Condition, is 60 DEG C in temperature, and confined pressure is to carry out distributary acid flowing experiment under 1MPa, according to " note base fluid → note turns to acid → note
Treatment fluid → note after pad → note displacement fluid → note base fluid " injection order, simulation turn to distributary acid process working fluid to enter
The flow process of reservoir.Flowing through core with base fluid in experimentation is to compare permeability before and after core is acidified to change situation.
The all each working fluid percentage by weights of low damage distributary acid:
Base fluid: SZ36-1 oil field stratum water.
Turn to acid: 12% hydrochloric acid, 6% diversion agent, 1% corrosion inhibiter, 1% ferrous stability, 1% clay stabilizer, 1%
Cleanup additive, 78% water.
Treatment fluid: 10% hydrochloric acid, 2% Fluohydric acid., 1% corrosion inhibiter, 1% ferrous stability, 1% clay stabilizer, 1%
Cleanup additive, 84% water.
After pad: 5% hydrochloric acid, 1% gel breaker, 1% corrosion inhibiter, 1% ferrous stability, 1% clay stabilizer, 1%
Cleanup additive, 90% water.
Displacement fluid: 3% aqueous ammonium chloride solution.
Diversion agent is erucyl amide hydroxysultaine, and corrosion inhibiter is 4-picoline, and ferrous stability is
Citric acid, clay stabilizer is polymeric aluminum chloride, and cleanup additive is perfluor 2,5,8-trimethyl-3,6,9-trioxa lauric acid/dodecanoic acids
(salt), gel breaker is butyl glycol ether.
Experimental result such as Fig. 1.1# core, 2# core original permeability extreme difference are relatively big, when an injection turns to latter two rock of acid
Core is close by the flow velocity turning to acid, illustrates that the core turning to acid to ooze height serves the effect of closure.Along with follow-up acid solution
The permeability injecting two cores is all gradually increased, and finally gives improvement, and the final penetrating power of 1# core is initial infiltration ability
1.17 times, the final penetrating power of 2# core is 5.33 times of initial infiltration ability, and after illustrating that employing turns to acid, acid solution is the most right
Low-permeable Cores serves more preferable improvement result.
Embodiment 2: in CNOOC's Bohai Sea as a example by the rock core simulating lab test of SZ36-1 oil field, be described in detail.
The side by side double cores using permeability different carry out flowing experiment simulation under formation conditions due to reservoir non-all
The fluid that matter causes is at the permeability of reservoir.3# core: the long 7cm of rock core, diameter 2.54cm, porosity 21.5%, permeability
487×10-3μm2, 4# core: the long 7cm of rock core, diameter 2.54cm, porosity 13.6%, permeability 98 × 10-3μm2.Simulated oil
Tibetan condition, is 90 DEG C in temperature, and confined pressure is to carry out distributary acid flowing experiment under 1MPa, according to " note base fluid → note turn to acid →
Note treatment fluid → note after pad → note displacement fluid → note base fluid " injection sequentially, simulate and turn to distributary acid process working fluid to enter
Enter the flow process of reservoir.Flowing through core with base fluid in experimentation is to compare permeability before and after core is acidified to change feelings
Condition.
The all each working fluid percentage by weights of low damage distributary acid:
Base fluid: SZ36-1 oil field stratum water.
Turn to acid: 13% hydrochloric acid, 5% diversion agent, 1% corrosion inhibiter, 1% ferrous stability, 1% clay stabilizer, 1%
Cleanup additive, 78% water.
Treatment fluid: 10% hydrochloric acid, 8% fluoboric acid, 1% corrosion inhibiter, 1% ferrous stability, 1% clay stabilizer, 1%
Cleanup additive, 78% water.
After pad: 5% hydrochloric acid, 1% gel breaker, 1% corrosion inhibiter, 1% ferrous stability, 1% clay stabilizer, 1%
Cleanup additive, 90% water.
Displacement fluid: 3% aqueous ammonium chloride solution.
Diversion agent is erucyl amide hydroxysultaine, and corrosion inhibiter is butynediols, and ferrous stability is
EDTA tetrasodium salt, clay stabilizer is polymeric aluminum chloride, and cleanup additive is perfluor 2,5,8-trimethyl-3,6,9-trioxas 12
Acid (salt), gel breaker is butyl glycol ether.
Experimental result such as Fig. 2.3# core, 4# core original permeability extreme difference are relatively big, when an injection turns to latter two rock of acid
Core is close by the flow velocity turning to acid, illustrates that the core turning to acid to ooze height serves the effect of closure.Along with follow-up acid solution
The permeability injecting two cores is all gradually increased, and finally gives improvement, and the final penetrating power of 3# core is initial infiltration ability
1.25 times, the final penetrating power of 4# core is 2.81 times of initial infiltration ability, and after illustrating that employing turns to acid, acid solution is the most right
Low-permeable Cores serves more preferable improvement result.Simultaneously in experimentation, when treatment fluid is by core, 3# core is than 4# rock
Core permeability is high, illustrates that note turns to acid to primarily enter height and oozes core during turning to acid, really serves and turn to acidifying
Effect.
The present invention turn to acid performance test:
1, acid viscosity B coefficent trend experiment is turned to
Experimental technique: under room temperature, prepares 20%HCl+3% diversion agent, the most gradually adds calcium carbonate reaction in acid solution,
Measuring the viscosity B coefficent process of acid solution, result is shown in Fig. 3.
In HCl concentration 12-15% interval, acid liquid viscosity is low, is suitable for sandstone reservoir acidizing treatment.
Reducing acid liquid viscosity with acid strength to increase rapidly, this can play rapidly the most stifled shunting after acid solution enters reservoir
Effect.
2, the temperature impact on turning to acid viscosity
Experimental technique: under different temperatures, prepares 15%HCl+5% diversion agent, the most gradually adds calcium carbonate in acid solution
Reaction, measures the viscosity B coefficent process of acid solution, and result is shown in Fig. 4.
At 60,90 DEG C, temperature will not impact turning to acid viscosity, can be used for temperature reservoirs.
3, acid is turned to stablize sandrock effect
Experimental technique: preparation other additives of 13%HCl+6% diversion agent+4%, pours Bohai Bay Oil oil-sand sample into by acid solution
In, and heating 90 DEG C of stirring 4h observations, result is shown in Fig. 5.
Acid solution and Reservoir Minerals can form stable gluey state after meeting, such that it is able to play the most stifled effect, cut
There is after cutting 2h good stablizing effect equally, do not interfere with the injection of follow-up acid solution in work progress and turn to turning to of acid
Effect.
4, acid gel breaking test is turned to
It is respectively adopted acid solution consumption, butyl and butyl glycol ether solution to turning to acid to carry out gel breaking test, knot
Fruit is shown in Table 1.
Experimental technique: first preparation high viscosity acid solution 8%HCl+6% diversion agent, turns to acid initial viscosity about
1000mpa.s。
(1) acid solution exhaust method, is gradually added into calcium carbonate solid turning to of preparing and consumes acid solution, to acid strength in acid
To 2%.
(2) take 2 samples of 100ml high viscosity acid solution, in acid solution, add 2ml butyl and 2ml ethylene glycol respectively
Butyl ether.
Table 1 turns to acid gel breaking test data
| Acid solution gel breaking method | Viscosity (mpa.s) after breaking gel | Broken glue rate |
| Calcium carbonate reaction consumes acid solution | 4.6 | 99.14% |
| Add butyl | 4.8 | 98.86% |
| Add butyl glycol ether | 4.3 | 99.35% |
As can be seen from Table 1: (1) turns to acid finally can realize acid solution with the consumption of acid solution and breaks glue, executing for the present invention
Even if acid solution can not the row of returning also can consume without damaging reservoir at reservoir with acid solution completely for a long time after work completes.
(2) in after pad, add butyl or butyl glycol ether can help to turn to sour broken glue.
5, acid turning efficiency experiment is turned to
Experimental technique: choose two pieces of big cores of permeability extreme difference, be sequentially injected into formation water, turn to acid, formation water.
(1) turn to acid to serve, after injecting, the effect turned to, and Low-permeable Cores is not caused plugging action.
(2) formation water finally makes two drill core permeability rates return to original state, illustrates to turn to acid will not ooze reservoir at height
Cause residual.
Acidifying be frscturing, the major measure of water injection well stimulation be also conventional measure, join product want when volume of production do not reach
Ask, water injection well does not reaches injection allocation requirement, generally will do once acidifying and improve in-place permeability, but owing to acidifying is repeated several times
After cause reservoir infiltration extreme difference big, then carry out acidifying acid solution will be made not distribute according to need, uniform acid distribution difficulty, acid solution de-plugging is imitated
The poorest.Being to use granule to block up distributary acid method temporarily currently for the solution that this problem is the most frequently used, the method was being constructed
Cheng Zhong, granule is not easily accessed reservoir deep, easily causes the blocking of the borehole wall.
The use self-diverting acid that the present invention proposes carries out distributary acid to sandstone heterogeneous reservoir, can make to turn to acid in storage
Layer depth portion carries out the most stifled shunting；When being injected simultaneously into reservoir be low viscosity fluid contribute to acidizing treatment will not the borehole wall formed blocking；
Turn to acid to be directly injected into stratum as prepad fluid, easy and simple to handle construction will not be given more difficult；Diversion agent is a kind of little molecule table
Face activating agent, will not introduce secondary injury to reservoir.
Embodiment 3: 11-6 oil field, prince wife Cao pasture D16H well, turns to acid field operation to describe in detail.
D16H well is water horizontal well, and on March 15th, 2008 goes into operation, horizontal section length 202m, and average production layer is the thickest
Degree 8m, the oversize general acidifying of well section is easy, easy construction, but owing to the oversize acid solution of well section is not easily accomplished uniformly dividing of each interval
Join, it is therefore necessary to use the mode turned to realize uniform acid distribution.Construction operation order is: after note prepad fluid → note treatment fluid → note
Put liquid → note prepad fluid → note treatment fluid → note after pad → note prepad fluid → note treatment fluid → note after pad → note displacement fluid.
D16H well turns to all each working fluid percentage by weights of distributary acid:
Turn to acid (prepad fluid): 13% hydrochloric acid, 6% diversion agent, 1% corrosion inhibiter, 1% ferrous stability, 1% clay is steady
Determine agent, 1% cleanup additive, 77% water.
Treatment fluid: 10% hydrochloric acid, 10% fluoboric acid, 1% corrosion inhibiter, 1% ferrous stability, 1% clay stabilizer,
1% cleanup additive, 76% water.
After pad: 5% hydrochloric acid, 1% gel breaker, 1% corrosion inhibiter, 1% ferrous stability, 1% clay stabilizer, 1%
Cleanup additive, 90% water.
Displacement fluid: 3% aqueous ammonium chloride solution.
Diversion agent is erucyl amide hydroxysultaine, and corrosion inhibiter is 4-picoline, and ferrous stability is
Citric acid, clay stabilizer is polymeric aluminum chloride, and cleanup additive is perfluor 2,5,8-trimethyl-3,6,9-trioxa lauric acid/dodecanoic acids
(salt), gel breaker is butyl glycol ether.
Experimental result such as Fig. 6.
Observing from construction curve figure, note prepad fluid is identical with note treatment fluid discharge capacity, but injection pressure during note treatment fluid
Quickly raise, it was demonstrated that prepad fluid achieves the effect turning to closure in reservoir.Production fluid 62m3/d, oil 28m3/ before this well acidizing
D, aqueous 54%, pressure reduction 6.9MPa.After acidifying, under same pressure differential, this well production fluid 124m3/d, oil 42m3/d, aqueous 66%, table
This time bright turns to acidizing treatment to be successful.
Claims (3)
1. a sandstone reservoir low damage distributary acid method, comprises the following steps successively:
(1) turn to acid as prepad fluid to sandstone reservoir injection；
(2) treatment fluid is injected to layer of sand reservoir；
(3) after pad is injected to sandstone reservoir；
(4) inject displacement fluid to pit shaft, the acid solution in pit shaft is headed into reservoir deep；
Described turn to acid composed of the following components: HCl 12-15%, diversion agent 3-10%, additive 4-8%, remaining is water, described
Diversion agent is erucyl amide hydroxysultaine, described additive include corrosion inhibiter 1-2%, ferrous stability 1-2%,
Clay stabilizer 1-2%, cleanup additive 1-2%；
Described treatment fluid applies to the various conventional treatment liquid of sandstone acidizing；
Described after pad is composed of the following components: HCl 5-15%, gel breaker 1-2%, additive 4-8%, and remaining is water, described broken
Colloid is butyl or butyl glycol ether, and described additive includes corrosion inhibiter 1-2%, ferrous stability 1-2%, clay
Stabilizer 1-2%, cleanup additive 1-2%；
Described displacement fluid is diesel oil, gasoline or 3% ammonium chloride solution；
Above component is mass percent.
2. a kind of sandstone reservoir low damage distributary acid method as claimed in claim 1, it is characterised in that described treatment fluid is
Mud acid system, fluoboric acid system, MH acid system, organic sandstone acid system or Compound-acid system.
3. a kind of sandstone reservoir low damage distributary acid method as claimed in claim 1, it is characterised in that described corrosion inhibiter is
4-picoline, butynediols, formaldehyde one or more of which, described ferrous stability be citric acid, nitrilotriacetic acid,
EDTA tetrasodium salt one or more of which, described clay stabilizer is polymeric aluminum chloride, and described cleanup additive is Polyethylene Glycol, perfluor
2,5,8-trimethyl-3,6,9-trioxa lauric acid/dodecanoic acid (salt) or its mixture.
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